Water sensing adaptable in-flow control device and method of use

ABSTRACT

A device and system for controlling fluid flow into a wellbore tubular may include a flow path in a production control device and at least one in-flow control element along the flow path. A media in the in-flow control element adjusts a cross-sectional flow area of the flow path by interacting with water. The media may be an inorganic solid, a water swellable polymer, or ion exchange resin beads. A method for controlling a fluid flow into a wellbore tubular may include conveying the fluid via a flow path from the formation into a flow bore of the wellbore; and adjusting a cross-sectional flow area of at least a portion of the flow path using a media that interacts with water. The method may include calibrating the media to permit a predetermined amount of flow across the media after interacts with water.

BACKGROUND OF THE DISCLOSURE

1. Field of the Disclosure

The disclosure relates generally to systems and methods for selectivecontrol of fluid flow into a production string in a wellbore.

2. Description of the Related Art

Hydrocarbons such as oil and gas are recovered from a subterraneanformation using a wellbore drilled into the formation. Such wells aretypically completed by placing a casing along the wellbore length andperforating the casing adjacent each such production zone to extract theformation fluids (such as hydrocarbons) into the wellbore. Theseproduction zones are sometimes separated from each other by installing apacker between the production zones. Fluid from each production zoneentering the wellbore is drawn into a tubing that runs to the surface.It is desirable to have substantially even drainage along the productionzone. Uneven drainage may result in undesirable conditions such as aninvasive gas cone or water cone. In the instance of an oil-producingwell, for example, a gas cone may cause an in-flow of gas into thewellbore that could significantly reduce oil production. In likefashion, a water cone may cause an in-flow of water into the oilproduction flow that reduces the amount and quality of the produced oil.Accordingly, it is desired to provide even drainage across a productionzone and/or the ability to selectively close off or reduce in-flowwithin production zones experiencing an undesirable influx of waterand/or gas.

The present disclosure addresses these and other needs of the prior art.

SUMMARY OF THE DISCLOSURE

In aspects, the present disclosure provides devices and related systemsfor controlling a flow of a fluid into a wellbore tubular in a wellbore.In one embodiment, a device may include a flow path associated with aproduction control device that conveys the fluid from the formation intoa flow bore of the wellbore tubular. At least one in-flow controlelement along the flow path includes a media that adjusts across-sectional flow area of at least a portion of the flow path byinteracting with water. The fluid may flow through the media and/orthrough an interspatial volume of the media. In one embodiment, thein-flow control element may include a chamber containing the media. Inanother embodiment, the at least one in-flow control element may includea channel having the media positioned on at least a portion of thesurface area defining the channel. The channel may have a firstcross-sectional flow area before the media interacts with water and asecond cross-sectional flow area after the media interacts with water.In embodiments, the media may be configured to interact with aregeneration fluid. Also, in embodiments, the media may be an inorganicsolid, including, but not limited to, silica vermiculite, mica,aluminosilicates, bentonite and mixtures thereof. In embodiments, themedia may be a water swellable polymer that includes, but not limitedto, a modified polystyrene. Also, the media may be ion exchange resinbeads.

In aspects, the present disclosure provides a method for controlling aflow of a fluid into a wellbore tubular in a wellbore. The method mayinclude conveying the fluid via a flow path from the formation into aflow bore of the wellbore; and adjusting a cross-sectional flow area ofat least a portion of the flow path using a media that interacts withwater. In embodiments, the method may include flowing the fluid throughthe media. The flowing may be through a first cross-sectional flow areabefore the media interacts with water and through a secondcross-sectional flow area after the media interacts with water. Inembodiments, the method may include calibrating the media to permit apredetermined amount of flow across the media after interacts withwater.

It should be understood that examples of the more important features ofthe disclosure have been summarized rather broadly in order thatdetailed description thereof that follows may be better understood, andin order that the contributions to the art may be appreciated. Thereare, of course, additional features of the disclosure that will bedescribed hereinafter and which will form the subject of the claimsappended hereto.

BRIEF DESCRIPTION OF THE DRAWINGS

The advantages and further aspects of the disclosure will be readilyappreciated by those of ordinary skill in the art as the same becomesbetter understood by reference to the following detailed descriptionwhen considered in conjunction with the accompanying drawings in whichlike reference characters designate like or similar elements throughoutthe several figures of the drawing and wherein:

FIG. 1 is a schematic elevation view of an exemplary multi-zonalwellbore and production assembly which incorporates an in-flow controlsystem in accordance with one embodiment of the present disclosure;

FIG. 2 is a schematic elevation view of an exemplary open holeproduction assembly which incorporates an in-flow control system inaccordance with one embodiment of the present disclosure;

FIG. 3 is a schematic cross-sectional view of an exemplary in-flowcontrol device made in accordance with one embodiment of the presentdisclosure;

FIG. 4 is a schematic cross sectional view of a first exemplaryembodiment of the in-flow control element of the disclosure;

FIG. 4 a is an excerpt from FIG. 4 showing the chamber of an embodimentof an in-flow control element filled with a particulate type media;

FIG. 5 is a schematic cross sectional view of a second exemplaryembodiment of an in-flow control element of the disclosure; and

FIGS. 6A and 6B are schematic cross-sectional views of a third exemplaryembodiment of an in-flow control element of the disclosure.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

The present disclosure relates to devices and methods for controllingproduction of a hydrocarbon producing well. The present disclosure issusceptible to embodiments of different forms. There are shown in thedrawings, and herein will be described in detail, specific embodimentsof the present disclosure with the understanding that the presentdisclosure is to be considered an exemplification of the principles ofthe disclosure, and is not intended to limit the disclosure to thatillustrated and described herein. Further, while embodiments may bedescribed as having one or more features or a combination of two or morefeatures, such a feature or a combination of features should not beconstrued as essential unless expressly stated as essential.

In one embodiment of the disclosure, in-flow of water into the wellboretubular of an oil well is controlled, at least in part using an in-flowcontrol element that contains a media that can interact with water influids produced from an underground formation. The media interactionwith water may be of any kind known to be useful in stopping ormitigating the flow of a fluid through a chamber filled with the media.These mechanisms include but are not limited to swelling, where themedia swells in the presence of water thereby impeding the flow of wateror water bearing fluids through the chamber.

Referring initially to FIG. 1, there is shown an exemplary wellbore 10that has been drilled through the earth 12 and into a pair of formations14, 16 from which it is desired to produce hydrocarbons. The wellbore 10is cased by metal casing, as is known in the art, and a number ofperforations 18 penetrate and extend into the formations 14, 16 so thatproduction fluids may flow from the formations 14, 16 into the wellbore10. The wellbore 10 has a deviated, or substantially horizontal leg 19.The wellbore 10 has a late-stage production assembly, generallyindicated at 20, disposed therein by a tubing string 22 that extendsdownwardly from a wellhead 24 at the surface 26 of the wellbore 10. Theproduction assembly 20 defines an internal axial flowbore 28 along itslength. An annulus 30 is defined between the production assembly 20 andthe wellbore casing. The production assembly 20 has a deviated,generally horizontal portion 32 that extends along the deviated leg 19of the wellbore 10. Production nipples 34 are positioned at selectedpoints along the production assembly 20. Optionally, each productiondevice 34 is isolated within the wellbore 10 by a pair of packer devices36. Although only two production devices 34 are shown in FIG. 1, theremay, in fact, be a large number of such production devices arranged inserial fashion along the horizontal portion 32.

Each production device 34 features a production control device 38 thatis used to govern one or more aspects of a flow of one or more fluidsinto the production assembly 20. As used herein, the term “fluid” or“fluids” includes liquids, gases, hydrocarbons, multi-phase fluids,mixtures of two of more fluids, water, brine, engineered fluids such asdrilling mud, fluids injected from the surface such as water, andnaturally occurring fluids such as oil and gas. Additionally, referencesto water should be construed to also include water-based fluids; e.g.,brine or salt water. In accordance with embodiments of the presentdisclosure, the production control device 38 may have a number ofalternative constructions that ensure selective operation and controlledfluid flow therethrough.

FIG. 2 illustrates an exemplary open hole wellbore arrangement 11wherein the production devices of the present disclosure may be used.Construction and operation of the open hole wellbore 11 is similar inmost respects to the wellbore 10 described previously. However, thewellbore arrangement 11 has an uncased borehole that is directly open tothe formations 14, 16. Production fluids, therefore, flow directly fromthe formations 14, 16, and into the annulus 30 that is defined betweenthe production assembly 21 and the wall of the wellbore 11. There are noperforations, and open hole packers 36 may be used to isolate theproduction control devices 38. The nature of the production controldevice is such that the fluid flow is directed from the formation 16directly to the nearest production device 34, hence resulting in abalanced flow. In some instances, packers maybe omitted from the openhole completion.

Referring now to FIG. 3, there is shown one embodiment of a productioncontrol device 100 for controlling the flow of fluids from a reservoirinto a flow bore 102 of a tubular 104 along a production string (e.g.,tubing string 22 of FIG. 1). This flow control can be a function of oneor more characteristics or parameters of the formation fluid, includingwater content, fluid velocity, gas content, etc. Furthermore, thecontrol devices 100 can be distributed along a section of a productionwell to provide fluid control at multiple locations. This can beadvantageous, for example, to equalize production flow of oil insituations wherein a greater flow rate is expected at a “heel” of ahorizontal well than at the “toe” of the horizontal well. Byappropriately configuring the production control devices 100, such as bypressure equalization or by restricting in-flow of gas or water, a wellowner can increase the likelihood that an oil bearing reservoir willdrain efficiently. Exemplary production control devices are discussedherein below.

In one embodiment, the production control device 100 includes aparticulate control device 110 for reducing the amount and size ofparticulates entrained in the fluids and an in-flow control device 120that controls overall drainage rate from the formation. The in-flowcontrol device 120 includes one or more flow paths between a formationand a wellbore tubular that may be configured to control one or moreflow characteristics such as flow rates, pressure, etc. The particulatecontrol device 110 can include known devices such as sand screens andassociated gravel packs. In embodiments, the in-flow control device 120utilizes one or more flow channels that control in-flow rate and/or thetype of fluids entering the flow bore 102 via one or more flow boreorifices 122. In embodiments, the in-flow control device 120 may includeone or more in-flow control element 130 that include a media 200 thatinteracts with one or more selected fluids in the in-flowing fluid toeither partially or completely block the flow of fluid into the flowbore 102. In one aspect, the interaction of the media 200 with a fluidmay be considered to be calibrated. By calibrate or calibrated, it ismeant that one or more characteristics relating to the capacity of themedia 200 to interact with water or another fluid is intentionally tunedor adjusted to occur in a predetermined manner or in response to apredetermined condition or set of conditions.

While the in-flow control element 130 and the media 200 are showndownstream of the particulate control device 110, it should beunderstood that the in-flow control element 130 and the media may bepositioned anywhere along a flow path between the formation and the flowbore 102. For instance, the in-flow control element 130 may beintegrated into the particulate control device 110 and/or any flowconduits such as channels 124 that may be used to generate a pressuredrop across the production control device 100. Illustrative embodimentsare described below.

Turning to FIG. 4, there is shown a first exemplary embodiment of anin-flow control element 130 of the disclosure that uses a media thatinteracts with a fluid to control fluid flow across the in-flow controldevice 120 (FIG. 3). The in-flow control element 130 includes a flowpath 204. A first and a second screen 202 a&b in the flow path 204define a chamber 206. A media 200 is located within the chamber 206. Themedia 200 may substantially completely fill the chamber 206 such thatthe fluid flowing along the flow path 204 passes through the media 200.

In this embodiment, as fluid from the formation passes through the media200, no substantial change in pressure occurs as long as the formationfluid includes comparatively low amounts of water. If a water incursioninto the formation fluid occurs, the media 200 interacts with theformation fluid to either partially or completely block the flow of theformation fluid.

In FIG. 4 a, an excerpt of FIG. 4 corresponding to the section of FIG. 4within the dotted circle shows an alternative embodiment of thedisclosure. In this embodiment, the media 200 a is particulate, such asa packed body of ion exchange resin beads and the chamber 206 (FIG. 4)is a fixed volume space. The beads may be formed as balls having littleor no permeability. When water flows through the chamber 206 (FIG. 4),the ion exchange resin increases in size by absorbing the water. Becausethe beads are relatively impermeable, the cross-sectional flow area isreduced by the swelling of the ion exchange resin. Thus, flow across thechamber 206 (FIG. 4) may be reduced or stopped.

FIG. 5 illustrates a second exemplary embodiment of an in-flow controlelement 130 of the disclosure. As in FIG. 4, the in-flow control element130 includes a flow path 204, and within the flow path 204, screens 202a&b define a chamber 206 containing a media 200. In this embodimentthere is also a valve 300 located between the chamber 206 containing themedia 200 and entrance to the in-flow control element 130. As drawn,this is a check valve, but in other embodiment, the valve may be anykind of valve that is able to restrict fluid flow in at least onedirection within the flow path 204. Also present is a feed line 302which is used to feed a regenerating fluid into the space between thevalve and the chamber 206.

In the exemplary embodiments shown in FIG. 4 and FIG. 5, screens 202 a&bare used to define a chamber 206 that includes the media 200. If themedia 200 is in the form of a pellet or powder, then a screen is logicalselection since it would hold the pellets or powder in place and stillallow the produced fluid to pass though the flow path 204 and throughthe media 200. The use of screens is not, however, a limitation on theinvention. The media 200 may be retained in the chamber 206 using anymethod known to those of ordinary skill in the art to be useful. Forexample, when the media 200 is solid polymer, it may be led in placewith a clamp or a retaining ring. Even when the media 200 is particulateother methods including membranes, filters, slit screens, porouspackings and the like may be so used.

Referring now to FIGS. 6A and 6B, there is shown a flow path 310 thatincludes a material 320 that may expand or contract upon interactingwith the fluid flowing in the flow path 310. For example, the flow path310 may have a first cross-sectional flow area 322 for a fluid that ismostly oil and have a second smaller cross-sectional flow area 324 for afluid that is mostly water. Thus, a greater pressure differential andlower flow rate may be imposed on the fluid that is mostly water. Theflow path 310 may be within the particulate control device 110 (FIG. 3),along the channels 124 (FIG. 3), or elsewhere along the productioncontrol device 100 (FIG. 3). The material 320 may be any of thosedescribed previously or described below. In embodiments, the material320 may be formed as a coating on a surface 312 of the flow path 310 oran insert positioned in the flow path 310. Other configurations known inthe art may also be used to fix or deposit the material 320 into theflow path 310. Moreover, it should be understood that the rectangularcross-sectional flow path is merely illustrative and other shapes (e.g.,circular). Also, the material 320 may be positioned on all or less thanall of the surfaces areas defining the flow path 310. In otherembodiments, the material 310 may be configured to completely seal offthe flow path 310.

In an exemplary mode of operation, the material 320 provides a firstcross-sectional area 322 in a non-interacting state and a second smallercross-sectional area 324 when reacting with a fluid, such as water.Thus, in embodiments, the material 320 does not swell or expand tocompletely seal the flow path 310 against fluid flow. Rather, fluid maystill flow through the flow path 310, but at a reduced flow rate. Thismay be advantageous where the formation is dynamic. For instance, atsome point, the water may dissipate and the fluid may return tocontaining mostly oil. Maintaining a relatively small and controlledflow rate may allow the material 320 to reset from the swollen conditionand form the larger cross-sectional area 322 for the oil flow.

In at least one embodiment of the disclosure, it may be desirable toregenerate the media 200 after it has interacted with water so that flowfrom the formation may be resumed. In such an embodiment, the valve 300may, for example, block the flow fluid in the direction of the formationallowing a feed of a regenerating fluid to be fed at a comparativelyhigh pressure through the media 200 in order to regenerate it.

One embodiment of the disclosure is a method for preventing ormitigating the flow of water into a wellbore tubular using an in-flowcontrol element. In one embodiment of the disclosure, the in-flowcontrol element can be used wherein the media is passive when the fluidbeing produced from the formation is comparatively high in hydrocarbons.As oil is produced from a formation, the concentration of water in thefluid being produced can increase to the point where it is not desirableto remover further fluid from the well. When the water in the fluidbeing produced reaches such a concentration, the media may interact withwater in the fluid to decrease the flow rate of production fluid throughthe in-flow control element.

One mechanism by which the water may interact with the media useful withembodiments of the disclosure is swelling. Swelling, for the purposes ofthis disclosure means increasing in volume. If the in-flow controlelement has a limited volume, and the media swells to point that theproduced fluid cannot pass through the media, then the flow is stopped,thus preventing or mitigating an influx of water into crude oilcollection systems at the surface. Swelling can occur in bothparticulate and solid media. For example, one media that may be usefulare water swellable polymers. Such polymers may be in the form ofpellets or even solids molded to fit within an in-flow control element.Any water swellable polymer that stable in downhole conditions and knownto those of ordinary skill in the art to be useful can be used in themethod of the disclosure.

Exemplary polymers include crosslinked polyacrylate salts; saponifiedproducts of acrylic acid ester-vinyl acetate copolymers; modifiedproducts of crosslinked polyvinyl alcohol; crosslinked products ofpartially neutralized polyacrylate salts; crosslinked products ofisobutylene-maleic anhydride copolymers; and starch-acrylic acid graftedpolymers. Other such polymers include poly-N-vinyl-2-pyrrolidone; vinylalkyl ether/maleic an hydride copolymers; vinyl alkyl ether/maleic acidcopolymers; vinyl-2-pyrrolidone/vinyl alkyl ether copolymers wherein thealkyl moiety contains from 1 to 3 carbon atoms, the lower alkyl estersof said vinyl ether/maleic anhydride copolymers, and the cross-linkedpolymers and interpolymers of these. Modified polystyrene andpolyolefins may be used wherein the polymer is modified to includefunctional groups that would cause the modified polymers to swell in thepresence of water. For example, polystyrene modified with ionicfunctional groups such as sulfonic acid groups can be used withembodiments of the disclosure. One such modified polystyrene is known asion exchange resin

Naturally occurring polymers or polymer derived from naturally occurringmaterials that may be useful include gum Arabic, tragacanth gum,arabinogalactan, locust bean gum (carob gum), guar gum, karaya gum,carrageenan, pectin, agar-agar, quince seed (i.e., marmelo), starch fromrice, corn, potato or wheat, algae colloid, and trant gum;bacteria-derived polymers such as xanthan gum, dextran, succinoglucan,and pullulan; animal-derived polymers such as collagen, casein, albumin,and gelatin; starch-derived polymers such as carboxymethyl starch andmethylhydroxypropyl starch; cellulose polymers such as methyl cellulose,ethyl cellulose, methylhydroxypropyl cellulose, carboxymethyl cellulose,hydroxymethyl cellulose, hydroxypropyl cellulose, nitrocellulose, sodiumcellulose sulfate, sodium carboxymethyl cellulose, crystallinecellulose, and cellulose powder; alginic acid-derived polymers such assodium alginate and propylene glycol alginate; vinyl polymers such aspolyvinyl methylether, polyvinylpyrrolidone. In one embodiment of thedisclosure, the media is ion exchange resin beads.

The swellable media may also include inorganic compounds. Silica may beprepared into silica gels that swell in the presence of water.Vermiculite and mica and certain clays such as aluminosilicates andbentonite can also be formed into water swellable pellets and powders.

Another group of materials that may be useful as a media includes thosethat, in the presence of water pack more compactly than in the presenceof a hydrocarbon. One such material is finely ground inert material thathas a highly polar coating. When packed into an in-flow control element.Any such material that is stable under downhole conditions may be usedwith the embodiments of the disclosure.

If an oil well includes a apparatus of the disclosure, and it isdesirable that the well be decommissioned upon a water incursion, suchas when an reservoir is undergoing water flooding secondary recovery,then the in-flow control device may be used downhole without anycommunication with the surface. If, on the other hand, the device isintended for long term use where even comparatively dry crude oil willeventually cause the media to reduce the flow of produced fluids orwhere it will be desirable to restart the flow of produced fluids aftersuch flow has been stopped, it may be desirable to regenerate or replacethe media within the in-flow control element.

The media may be regenerated by any method known to be useful to thoseof ordinary skill in the art to do so. One method useful forregenerating the media may be to expose the media to a flow of aregenerating fluid. In one such embodiment, the fluid may be pumped downthe tubular from the surface at a pressure sufficient to force theregenerating fluid through the media. In an alternative embodiment whereit is not desirable to force regeneration fluid into the formation, anapparatus such as that in FIG. 5. may be used. In such an embodiment, aregeneration fluid is forced down hole through the feed tube 302 andinto the space between the valve 300 and chamber 206. If the valve is acheck valve, then the regenerating fluid my be simple pumped into thisspace at a pressure sufficient to force the fluid through the media andinto the tubular since the check valve will prevent back flow into theformation. If the valve is not a check valve then it may need to beclosed prior to starting the regeneration fluid flow.

Regenerating fluids may have at least two properties. The first is thatthe regenerating fluid should have a greater affinity for water than themedia. The second is that the regenerating fluid should cause little orno degradation of the media. Just as there are may compounds that may beused as the media of the disclosure, there may also be many liquids thatcan function as the regenerating fluid. For example, if the media is aninorganic powder or pellet, then methanol, ethanol, propanol,isopropanol, acetone, methyl ethyl ketone, and the like may be used as aregenerating fluid is some oil wells. If the media is a polymer that issensitive to such materials or if a higher boiling point regeneratingfluid is need, then some of the commercial poly ether alcohols, forexample may be used. One of ordinary skill in the art of operating anoil well will understand how to select a regenerating fluid that iseffective at downhole conditions and compatible with the media to betreated.

Referring now to FIGS. 6A and 6B, in other variants, the material 320 inthe flow path 310 may be configured to operate according to HPLC (highperformance liquid chromatography). The material 320 may include one ormore chemicals that may separate the constituent components of a flowingfluid (e.g., oil and water) based on factors such as dipole-dipoleinteractions, ionic interactions or molecule sizes. For example, as isknown, an oil molecule is size-wise larger than a water molecule. Thus,the material 320 may be configured to be penetrable by water butrelatively impenetrable by oil. Such a material then would retain water.In another example, ion-exchange chromatography techniques may be usedto configure the material 320 to separate the fluid based on the chargeproperties of the molecules. The attraction or repulsion of themolecules by the material may be used to selectively control the flow ofthe components (e.g., oil or water) in a fluid.

Inflow control elements of the disclosure may be particularly useful inan oil field undergoing secondary recovery such as water flooding. Oncewater break through from the flooding occurs, the in-flow control devicemay, in effect, block the flow of fluids permanently thus preventing anincursion of large amounts of water into the crude oil being recovered.The in-flow control device, or perhaps only the in-flow control elementmay be removed if the operator of the well deems it advisable tocontinue using the well. For example, such a well may be useful forcontinuing the water flooding of the formation.

It should be understood that FIGS. 1 and 2 are intended to be merelyillustrative of the production systems in which the teachings of thepresent disclosure may be applied. For example, in certain productionsystems, the wellbores 10, 11 may utilize only a casing or liner toconvey production fluids to the surface. The teachings of the presentdisclosure may be applied to control flow through these and otherwellbore tubulars.

For the sake of clarity and brevity, descriptions of most threadedconnections between tubular elements, elastomeric seals, such aso-rings, and other well-understood techniques are omitted in the abovedescription. Further, terms such as “slot,” “passages,” and “channels”are used in their broadest meaning and are not limited to any particulartype or configuration. The foregoing description is directed toparticular embodiments of the present disclosure for the purpose ofillustration and explanation. It will be apparent, however, to oneskilled in the art that many modifications and changes to the embodimentset forth above are possible without departing from the scope of thedisclosure.

1. An apparatus for controlling a flow of a fluid into a wellboretubular in a wellbore, comprising: a flow path associated with aproduction control device, the flow path configured to convey the fluidfrom the formation into a flow bore of the wellbore tubular; aparticulate control device positioned along the flow path; and at leastone in-flow control element along the flow path and downstream of theparticulate control device, the in-flow control element including aparticulated media that reduces a flow rate in at least a portion of theflow path by interacting with water, wherein the particulated mediaseparates the fluid based on molecular charge and is configured tomaintain a flow of the fluid across the media and not completely sealthe flow path after interacting with water.
 2. The apparatus of claim 1wherein the media is configured to increase flow across the in-flowcontrol element as water in the fluid dissipates.
 3. The apparatus ofclaim 1 wherein the particulated media is packed and wherein the fluidflows through an interspatial volume of the particulated media.
 4. Theapparatus of claim 1 wherein the media is configured to interact with aregeneration fluid.
 5. The apparatus of claim 1 wherein the mediaincludes is an inorganic solid.
 6. The apparatus of claim 1 wherein themedia is ion exchange resin beads.
 7. A method for controlling a flow ofa fluid into a wellbore tubular in a wellbore, comprising: conveying thefluid via a flow path from a particulate control device into a flow boreof the wellbore; and adjusting a cross-sectional flow area of at least aportion of the flow path using a particulated media that interacts withwater and separates the fluid based on molecular charge whilemaintaining a flow of the fluid across the media without completelysealing the flow path.
 8. The method of claim 7 further comprisingincreasing flow along the flow path as water in the fluid dissipates. 9.The method of claim 7 wherein the media includes an inorganic solid. 10.A system for controlling a flow of a fluid in a well, comprising: awellbore tubular in the well; a production control device positionedalong the wellbore tubular; a particulate control device associated withthe production control device; a flow path associated with theproduction control device, the flow path configured to convey the fluidfrom the particulate control device into a flow bore of the wellboretubular; and at least one in-flow control element along the flow path,the in-flow control element including a media that adjusts flow along atleast a portion of the flow path by interacting with water, wherein themedia interacts with molecules of a component of the fluid byattraction, and wherein the media is fixed to a surface of the flow pathand configured to maintain a flow of the fluid along the flow path andnot completely seal the flow path after interacting with water.
 11. Thesystem of claim 10 wherein the media is one of: (i) a coating on thesurface, and (ii) an insert positioned on the surface.
 12. The system ofclaim 10 wherein the media is configured to increase flow across thein-flow control element as water in the fluid dissipates.
 13. Anapparatus for controlling a flow of a fluid into a wellbore tubular in awellbore, comprising: a flow path associated with a production controldevice, the flow path configured to convey the fluid from the formationinto a flow bore of the wellbore tubular; a particulate control devicepositioned along the flow path; and at least one in-flow control elementalong the flow path and downstream of the particulate control device,the in-flow control element including a particulated media that reducesa flow rate in at least a portion of the flow path by interacting withwater, wherein the particulated media separates the fluid based onmolecular size and is configured to maintain a flow of the fluid acrossthe media and not completely seal the flow path after interacting withwater.
 14. The apparatus of claim 13 wherein the media is configured toincrease flow across the in-flow control element as water in the fluiddissipates.
 15. The apparatus of claim 13 wherein the particulated mediais packed and wherein the fluid flows through an interspatial volume ofthe particulated media.
 16. An apparatus for controlling a flow of afluid into a wellbore tubular in a wellbore, comprising: a flow pathassociated with a production control device, the flow path configured toconvey the fluid from the formation into a flow bore of the wellboretubular; a particulate control device positioned along the flow path;and at least one in-flow control element along the flow path anddownstream of the particulate control device, the in-flow controlelement including a particulated media that reduces a flow rate in atleast a portion of the flow path by interacting with water, wherein theparticulated media includes a polar coating and is configured tomaintain a flow of the fluid across the media and not completely sealthe flow path after interacting with water.
 17. The apparatus of claim16 wherein the media is configured to increase flow across the in-flowcontrol element as water in the fluid dissipates.
 18. The apparatus ofclaim 16 wherein the particulated media is packed and wherein the fluidflows through an interspatial volume of the particulated media.
 19. Asystem for controlling a flow of a fluid in a well, comprising: awellbore tubular in the well; a production control device positionedalong the wellbore tubular; a particulate control device associated withthe production control device; a flow path associated with theproduction control device, the flow path configured to convey the fluidfrom the particulate control device into a flow bore of the wellboretubular; and at least one in-flow control element along the flow path,the in-flow control element including a media that adjusts flow along atleast a portion of the flow path by interacting with water, wherein themedia interacts with molecules of a component of the fluid by repulsion,and wherein the media is fixed to a surface of the flow path andconfigured to maintain a flow of the fluid along the flow path and notcompletely seal the flow path after interacting with water.
 20. Thesystem of claim 19 wherein the media is configured to increase flowacross the in-flow control element as water in the fluid dissipates.